U.S. patent number 10,107,261 [Application Number 15/101,001] was granted by the patent office on 2018-10-23 for system and method for reducing oscillation loads of wind turbine.
This patent grant is currently assigned to General Electric Company. The grantee listed for this patent is Timothy Botsford Cribbs, Jignesh Govindlal Gandhi, General Electric Company, William Edwin Holley, Xiongzhe Huang, Raveendra Penmatsa, Conner B. Shane, Danian Zheng. Invention is credited to Timothy Botsford Cribbs, Jignesh Govindlal Gandhi, William Edwin Holley, Xiongzhe Huang, Raveendra Penmatsa, Conner B. Shane, Danian Zheng.
United States Patent |
10,107,261 |
Zheng , et al. |
October 23, 2018 |
System and method for reducing oscillation loads of wind
turbine
Abstract
A system and method for reducing oscillation loads of a wind
turbine induced by high turbulence and/or combined with other
environmental conditions are provided. The method includes
determining at least one wind parameter at the wind turbine;
monitoring an operating condition of the wind turbine; determining,
by a processor, a variance of at least one of the monitored
operating condition or a plurality of the wind parameters, wherein
the variance is indicative of an oscillation occurring at one or
more wind turbine components; determining, by a processor, an
operating set point based on the variance; and, operating the wind
turbine based on the operating set point when the variance
indicates that the oscillation has a frequency within a certain
frequency band so as to modify the frequency, wherein the modified
frequency is outside of the frequency band and reduces oscillation
loads occurring at the one or more wind turbine components.
Inventors: |
Zheng; Danian (Fairfield,
CT), Huang; Xiongzhe (Shanghai, CN), Holley;
William Edwin (Greer, SC), Shane; Conner B. (Glenville,
NY), Penmatsa; Raveendra (Bangalore, IN), Gandhi;
Jignesh Govindlal (Simpsonville, SC), Cribbs; Timothy
Botsford (Roanoke, VA) |
Applicant: |
Name |
City |
State |
Country |
Type |
General Electric Company
Zheng; Danian
Huang; Xiongzhe
Holley; William Edwin
Shane; Conner B.
Penmatsa; Raveendra
Gandhi; Jignesh Govindlal
Cribbs; Timothy Botsford |
Schenectady
Fairfield
Shanghai
Greer
Glenville
Bangalore
Simpsonville
Roanoke |
NY
CT
N/A
SC
NY
N/A
SC
VA |
US
US
CN
US
US
IN
US
US |
|
|
Assignee: |
General Electric Company
(Schenectady, NY)
|
Family
ID: |
53370437 |
Appl.
No.: |
15/101,001 |
Filed: |
December 9, 2013 |
PCT
Filed: |
December 09, 2013 |
PCT No.: |
PCT/CN2013/088885 |
371(c)(1),(2),(4) Date: |
June 02, 2016 |
PCT
Pub. No.: |
WO2015/085465 |
PCT
Pub. Date: |
June 18, 2015 |
Prior Publication Data
|
|
|
|
Document
Identifier |
Publication Date |
|
US 20160305403 A1 |
Oct 20, 2016 |
|
Current U.S.
Class: |
1/1 |
Current CPC
Class: |
F03D
17/00 (20160501); G05B 19/042 (20130101); F03D
7/0296 (20130101); F03D 7/0244 (20130101); F03D
7/042 (20130101); F03D 7/0224 (20130101); F03D
15/10 (20160501); F03D 9/25 (20160501); Y02E
10/72 (20130101); G05B 2219/2619 (20130101); F05B
2270/334 (20130101) |
Current International
Class: |
G05D
7/00 (20060101); F03D 7/04 (20060101); G05B
19/042 (20060101); F03D 17/00 (20160101); F03D
7/02 (20060101); F03D 15/10 (20160101); F03D
9/25 (20160101) |
References Cited
[Referenced By]
U.S. Patent Documents
Foreign Patent Documents
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|
0847496 |
|
Aug 2000 |
|
EP |
|
1075600 |
|
Aug 2002 |
|
EP |
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WO9709531 |
|
Mar 1997 |
|
WO |
|
Other References
Extended European Search Report and Opinion issued in connection
with corresponding EP Application No. 13898996.7 dated Jul. 6,
2017. cited by applicant .
International Search Report of PCT/CN2013/088885 dated Sep. 9,
2014. cited by applicant.
|
Primary Examiner: Tran; Vincent
Attorney, Agent or Firm: Dority & Manning, P.A.
Claims
What is claimed is:
1. A method for reducing oscillation loads of a wind turbine
induced by high turbulence or combined with other environmental
conditions, the method comprising: determining at least one wind
parameter at the wind turbine; monitoring an operating condition of
the wind turbine; determining, by a processor, a variance of at
least one of the monitored operating condition or a plurality of
the wind parameters, wherein the variance is indicative of an
oscillation occurring at one or more wind turbine components;
determining, by the processor, an operating set point based on the
variance and an electrical capability of the wind turbine, the
electrical capability of the wind turbine being a function of at
least a torque availability of the wind turbine; and, operating the
wind turbine based on the operating set point when the variance
indicates that the oscillation comprises a frequency within a
certain frequency band so as to modify the frequency, wherein the
modified frequency is outside of the frequency band and reduces
oscillation loads occurring at the one or more wind turbine
components.
2. The method of claim 1, wherein the frequency band comprises one
of a predetermined frequency band or a computed frequency band.
3. The method of claim 1, wherein the frequency band comprises one
or more resonance frequencies of the one or more wind turbine
components.
4. The method of claim 1, wherein the one or more wind turbine
components comprise a rotor blade of the wind turbine, and wherein
the variance is indicative of one of a blade-edge oscillation or a
blade-flap oscillation.
5. The method of claim 1, wherein the at least one wind parameter
is reflective of any one of or combination of the following: a wind
gust, a wind speed, a wind direction, a wind acceleration, a wind
turbulence, a wind shear, a wind veer, or a wake.
6. The method of claim 1, wherein the step of determining the at
least one wind parameter at the wind turbine further comprises at
least one of the following: utilizing one or more sensors to
measure the wind parameter or estimating the wind parameter,
wherein estimating the wind parameter comprises one of or
combination of the following: one or more operating conditions of
the wind turbine, a plurality of equations, one or more aerodynamic
performance maps, one or more look-up tables, or one or more
adaptive parameters of the wind turbine.
7. The method of claim 1, wherein the step of determining the at
least one wind parameter further comprises filtering the plurality
of wind parameters.
8. The method of claim 7, wherein the step of filtering the
plurality of wind parameters further comprises utilizing one of or
a combination of a low-pass filter, a high-pass filter, or a
band-pass filter.
9. The method of claim 1, wherein the monitored operating condition
comprises any one of or a combination of the following: a pitch
angle, a generator speed, a power output, or a torque output.
10. The method of claim 1, further comprising determining a
standard deviation of the monitored operating condition, and
determining the variance of the monitored operating condition based
at least partially on the standard deviation.
11. The method of claim 10, further comprising utilizing a filter
to stabilize the standard deviation of the monitored operating
condition.
12. The method of claim 1, further comprising inputting the
operating set point into one of a filter or an S-function to
stabilize a transition to the operating set point.
13. The method of claim 1, wherein the step of operating the wind
turbine based on the operating set point further comprises at least
one of de-rating or up-rating the wind turbine, wherein de-rating
or up-rating the wind turbine further comprises modifying one of or
a combination of a generator speed, a torque demand, a pitch angle
of a rotor blade, a power output, an orientation of a nacelle of
the wind turbine, a load bank, a buck-boost mechanism, or actuating
one or more airflow modifying elements.
14. A method for reducing oscillation loads of a wind turbine
induced by high turbulence or combined with other environmental
conditions, the method comprising: monitoring a generator speed of
the wind turbine; determining, by a processor, a generator speed
variance from a plurality of monitored generator speeds, wherein
the generator speed variance is indicative of an oscillation
occurring at one or more wind turbine components; determining, by
the processor, an operating set point based on the variance of the
plurality of monitored generator speeds and an electrical
capability of the wind turbine, the electrical capability of the
wind turbine being a function of at least a torque availability of
the wind turbine; operating the wind turbine based on the operating
set point when the variance indicates that the oscillation
comprises a frequency within a certain frequency band so as to
modify the frequency of the oscillation, wherein the modified
frequency is outside of the frequency band and reduces oscillation
loads occurring at the one or more wind turbine components.
15. A system for reducing oscillation loads of a wind turbine
induced by high turbulence or combined with other environmental
conditions, the system comprising: a processor configured to:
determine at least one wind parameter at the wind turbine, monitor
an operating condition of the wind turbine; determine a variance of
at least one of the monitored operating condition or a plurality of
the wind parameters, wherein the variance is indicative of an
oscillation occurring at one or more wind turbine components;
determine an operating set point based on the variance and an
electrical capability of the wind turbine, the electrical
capability of the wind turbine being a function of at least a
torque availability of the wind turbine; and, a controller
communicatively coupled to the processor, wherein the controller is
configured to operate the wind turbine based on the operating set
point when the variance indicates that the oscillation comprises a
frequency within a certain frequency band so as to modify the
frequency, wherein the modified frequency is outside of the
frequency band and reduces oscillation loads occurring at the one
or more wind turbine components.
16. The system of claim 15, wherein the frequency band comprises
one or more resonance frequencies of the one or more wind turbine
components.
17. The system of claim 15, wherein the one or more wind turbine
components comprise a rotor blade of the wind turbine, and wherein
the variance is indicative of one of a blade-edge oscillation or a
blade-flap oscillation.
18. The system of claim 15, wherein the processor further comprises
at least one low-pass filter or S-function, wherein the at least
low-pass filter or S-function function is configured to stabilize
any of the following: a plurality of measured or estimated wind
parameters, the monitored operating condition, or one or more
operating set points.
Description
FIELD OF THE INVENTION
The present subject matter relates generally to wind turbines and,
more particularly, to a system and method for reducing oscillation
loads in a wind turbine induced by high turbulence and/or combined
with other environmental conditions.
BACKGROUND OF THE INVENTION
Wind power is considered one of the cleanest, most environmentally
friendly energy sources presently available and wind turbines have
gained increased attention in this regard. A modern wind turbine
typically includes a tower, a generator, a gearbox, a nacelle, and
one or more rotor blades. The rotor blades are the primary elements
for converting wind energy into electrical energy. The blades
typically have the cross-sectional profile of an airfoil such that,
during operation, air flows over the blade producing a pressure
difference between its sides. Consequently, a lift force, which is
directed from the pressure side towards the suction side, acts on
the blade. The lift force generates torque on the main rotor shaft,
which is geared to a generator for producing electricity.
During initial start-up of a wind turbine, oscillations occur in
various wind turbine components as the generator speed is increased
to rated speed. The oscillations of the individual components have
a tendency to excite the wind turbine when the frequency of the
oscillations equals one of the resonance frequencies of the wind
turbine, which is the frequency at which the response amplitude is
a relative maximum. As used herein, the term "resonance" is meant
to encompass the tendency of a wind turbine component to oscillate
with greater amplitude at some frequencies than at others and/or a
vibration of large amplitude produced by a relatively small
vibration near the same frequency of vibration as the natural
frequency of the resonating system or band of frequencies. In
addition, the resonance may be due to the coupling effect of the
tower with the pitch drive mechanism and/or the coupling effect of
the tower with the speed regulator. At such frequencies, even small
periodic excitation actions can produce large amplitude
oscillations, because the component is capable of storing
vibrational energy.
As such, various control technologies have been implemented to
control the generator speed of the wind turbine during start-up to
avoid components from oscillating at one of their resonance
frequencies. For example, various control technologies determine a
speed exclusion zone for the generator and prevent the generator
speed from operating in this zone for longer than a predetermined
time period to avoid exciting the system. The speed exclusion zone
of a wind turbine typically refers to a region within the
variable-speed region of the wind turbine where the generator is
not allowed to operation for sustained periods. Such control
strategies, however, are typically only concerned with start-up
conditions of the wind turbine and do not consider oscillations
caused by high turbulence intensity and/or other environmental
conditions combined with wind turbine operational status that occur
during subsequent operation.
For example, as wind speeds vary and create turbulence on the wind
turbine, the generator speed correspondingly varies and can excite
resonance frequencies of various wind turbine components, thereby
causing oscillation and/or resonance loads that can damage the wind
turbine. More specifically, the rotor blades tend to experience
edgewise oscillations or vibrations and/or resonance behavior at
high turbulence that increases the blade-edge loads above design
loads. Rotor blade edge-wise oscillations occur in the chord-wise
direction of the rotor blade between the leading edge and the
trailing edge and can damage the blade due to little damping
directed to such oscillations.
Further control strategies reduce and/or prevent various wind
turbine component loading by shutting down the wind turbine above a
certain (cut out) wind speed in an effort to minimize loads. Though
this strategy prevents damaging loads that might occur due to the
higher turbulence in the wind, a disadvantage is the lack of energy
capture in the region above the cut out wind speed. Also, a brief
increase in wind speed might trigger a turbine shutdown, while the
recovery to normal power production may take some time. On the same
token, the occurrence of high turbulence at rated wind speeds will
also increase the likelihood of triggering a turbine shutdown.
Still further control technologies reduce and/or prevent various
wind turbine component loading by measuring a wind speed via a
sensor and implementing a control a control action when wind speeds
indicate turbulent conditions. Such strategies, however, do not
consider resonance and/or oscillation loads as described
herein.
Accordingly, an improved system and method for reducing oscillation
loads of a wind turbine due to high turbulence and/or combined with
other environmental conditions would be desired in the art.
BRIEF DESCRIPTION OF THE INVENTION
Aspects and advantages of the invention will be set forth in part
in the following description, or may be obvious from the
description, or may be learned through practice of the
invention.
In one aspect, the present subject matter is directed to a method
for reducing oscillation loads of a wind turbine due to high
turbulence or combined with other environmental conditions. The
method includes determining at least one wind parameter at the wind
turbine; monitoring an operating condition of the wind turbine;
determining, by a processor, a variance of at least one of the
monitored operating condition or a plurality of the wind
parameters, wherein the variance is indicative of an oscillation
occurring at a wind turbine component; determining, by a processor,
an operating set point based on the variance; and, operating the
wind turbine based on the operating set point when the variance
indicates that the oscillation has a frequency within a certain
frequency band so as to modify the frequency, wherein the modified
frequency is outside of the frequency band and reduces oscillation
loads occurring at the one or more wind turbine components.
In another embodiment, the frequency band may include one of a
predetermined frequency band or a computed frequency band. In still
further embodiments, the frequency band may include one or more
resonance frequencies of the one or more wind turbine components.
In a further embodiment, the wind turbine component may include a
rotor blade of the wind turbine, wherein the variance may be
indicative of a blade-edge oscillation or a flap-wise oscillation.
In another embodiment, the wind parameter may be reflective of any
one of the following: a wind gust, a wind speed, a wind direction,
a wind acceleration, a wind turbulence, a wind shear, a wind veer,
a wake, or similar. In still another embodiment, the step of
determining the at least one wind parameter at the wind turbine may
further include utilizing one or more sensors to measure the at
least one wind parameter. In addition, the step of determining the
at least one wind parameter may include estimating the wind
parameter utilizing any combination of the following: one or more
operating conditions of the wind turbine, a plurality of equations,
one or more aerodynamic performance maps, one or more look-up
tables (LUTs), one or more adaptive parameters of the wind turbine
and/or derivations from any form of rotor/generator speed that is
calculated or derived with respect to the pitch angles and/or the
generator flux. The adaptive parameters of the wind turbine may be
any changing parameter of the wind turbine, including, but not
limited to previous operating experience, historical data, adaptive
inputs, coefficients, gains, losses, constants, or similar.
In still another embodiment, the step of determining the at least
one wind parameter may further include filtering a plurality of
wind parameters to more accurately determine the wind parameter. In
addition, the step of filtering the plurality of wind parameters to
more accurately determine the wind parameter may further include
utilizing a low-pass filter, a band-pass filter, or any other
suitable filter.
In various embodiments, the operating conditions may be any of the
following: a pitch angle/speed, rotor/generator speed, a power
output, a torque/generator flux measurement output, or similar. In
yet another embodiment, the method may include determining a
standard deviation of the plurality of operating conditions, and
determining the variance based, at least in part, on the standard
deviation. Further, the method may include utilizing a filter to
stabilize the standard deviation of the plurality of operating
conditions.
In additional embodiments, the step of determining the operating
set point based the variance may further include considering the
electrical capability of the wind turbine, wherein the electrical
capability of the wind turbine is a function of at least a torque
availability of the wind turbine. In still further embodiments, the
method may include inputting the operating set point into either a
filter or an S-function to stabilize a transition to the operating
set point.
In yet another embodiment, the step of operating the wind turbine
based on the operating set point further includes at least one of
de-rating or up-rating the wind turbine. In addition, the step of
de-rating or up-rating the wind turbine may further include
modifying any one of or a combination of the following: a generator
speed, a torque demand and/or speed, a pitch angle of a rotor
blade, a power output, an orientation of a nacelle of the wind
turbine, a load bank, a buck boost mechanism, actuating one or more
airflow modifying elements, and/or similar.
In another aspect, a method for reducing oscillation loads of a
wind turbine due to high turbulence or combined with other
environmental conditions is disclosed. The method includes
monitoring a generator speed of the wind turbine; determining, by a
processor, a generator speed variance from a plurality of monitored
generator speeds, wherein the variance is indicative of an
oscillation occurring at one or more wind turbine components;
determining, by the processor, an operating set point based on the
variance; and, operating the wind turbine based on the operating
set point when the variance of the plurality of generator speeds
indicates that the oscillation has a frequency within a certain
frequency band so as to modify the frequency, wherein the modified
frequency is outside of the frequency band and reduces oscillation
loads occurring at the one or more wind turbine components induced
by high turbulence intensity.
In still another aspect, the present subject matter is directed to
a system for reducing oscillation loads in a wind turbine due to
high turbulence or combined with other environmental conditions.
The system includes a processor and a controller communicatively
coupled to the processor. The processor is configured to: determine
at least one wind parameter at the wind turbine, monitor an
operating condition of the wind turbine, determine a variance of at
least one of the monitored operating condition or a plurality of
the wind parameters, wherein the variance is indicative of an
oscillation occurring in one or more wind turbine components, and
determine an operating set point based the variance. The controller
is configured to operate the wind turbine based on the operating
set point when the variance indicates the oscillation has a
frequency within a certain frequency band so as to modify the
frequency, wherein the modified frequency is outside of the
frequency band and reduces oscillation loads occurring at the one
or more wind turbine components.
In another embodiment of the system, the frequency band may include
one or more resonance frequencies of the one or more wind turbine
components. In addition, the one or more wind turbine components
may be a rotor blade of the wind turbine, wherein the variance is
indicative of a blade-edge oscillation and/or a flap oscillation,
or similar.
In a further embodiment, the system may further include one or more
sensors configured to measure one or more wind parameters and/or
the operating conditions. In yet another embodiment, the processor
may further include one or more low-pass filters configured to
filter any of the following: a plurality of measured and/or
estimated wind parameters and/or one or more operating set points.
In still additional embodiments, the processor may further include
one or S-functions, wherein the operating set point is an input for
the S-function such that the S-function is configured to stabilize
a transition to the operating set point. The system may also be
configured to implement any of the steps of the method as described
herein.
These and other features, aspects and advantages of the present
invention will become better understood with reference to the
following description and appended claims. The accompanying
drawings, which are incorporated in and constitute a part of this
specification, illustrate embodiments of the invention and,
together with the description, serve to explain the principles of
the invention.
BRIEF DESCRIPTION OF THE DRAWINGS
A full and enabling disclosure of the present invention, including
the best mode thereof, directed to one of ordinary skill in the
art, is set forth in the specification, which makes reference to
the appended figures, in which:
FIG. 1 illustrates a perspective view of one embodiment of a wind
turbine according to the present disclosure;
FIG. 2 illustrates an internal view of one embodiment of a nacelle
of a wind turbine according to the present disclosure;
FIG. 3 illustrates a schematic diagram of one embodiment of a
controller according to the present disclosure;
FIG. 4 illustrates a schematic diagram of one embodiment of a
processor according to the present disclosure; and,
FIG. 5 illustrates a flow diagram of a method according to the
present disclosure.
DETAILED DESCRIPTION OF THE INVENTION
Reference now will be made in detail to embodiments of the
invention, one or more examples of which are illustrated in the
drawings. Each example is provided by way of explanation of the
invention, not limitation of the invention. In fact, it will be
apparent to those skilled in the art that various modifications and
variations can be made in the present invention without departing
from the scope or spirit of the invention. For instance, features
illustrated or described as part of one embodiment can be used with
another embodiment to yield a still further embodiment. Thus, it is
intended that the present invention covers such modifications and
variations as come within the scope of the appended claims and
their equivalents.
Generally, the present subject matter is directed to a system and
method for reducing oscillation loads of a wind turbine due to high
turbulence and/or combined with other environmental conditions. The
environmental conditions can be any environmental condition that
causes an oscillation on one or more wind turbine components,
including, wind peaks, wind shear, changes in wind direction, air
density, and/or similar. As such, the present disclosure allows the
wind turbine to continue to operate at higher cut-out wind speeds
under high turbulence intensity levels. More specifically, the
present subject matter is configured to detect or infer an
oscillation occurring at a wind turbine component, e.g. a rotor
blade, by determining a wind speed and corresponding generator
speed and determining a variance in either the wind speed and/or
the generator speed. As used herein, the terms "oscillate" or
"oscillations" are meant to encompass any back-and-forth,
up-and-down, and/or side-to-side movements of a wind turbine
component including, but not limited to, any movements due to tower
shadow, tower dam, wind shear, and/or turbulence intensity. In
addition, the oscillations may also encompass any form of direct
and/or indirect measurement by one or more sensors (e.g.
accelerometers and/or gauges) that can be mounted in the wind
turbine.
If the variance indicates that the oscillation of the wind turbine
component has a frequency within a certain frequency band, e.g. a
frequency at or near one or more resonance frequencies, the system
is capable of modifying the frequency such that the modified
frequency is no longer within the frequency band so as to prevent
oscillation loads from damaging the wind turbine component. In one
embodiment, for example, the present disclosure utilizes a
combination of estimated and/or real wind speed and generator
speed/wind speed variance to de-rate or up-rate the wind turbine
(e.g. by adjusting the generator speed, torque speed, or both) to
avoid edge-wise blade resonance and reduce blade edge loads. In
addition, the de-rate/up-rate may consider the electrical
capability of the wind turbine such that a modified operating set
point, e.g. a torque demand and/or a generator speed demand, is
actually achievable. In addition, the present disclosure may
utilize a series of low pass filters and S-functions to make
transitioning to a selected operating set point smooth and
stable.
The various embodiments of the system and method described herein
provide numerous advantages. For example, the present disclosure
reduces and/or prevents oscillation loads induced by high
turbulence intensity from damaging the wind turbine, while also
increasing the cut-out wind speed to help customers secure a higher
Annual Energy Production (AEP). Further, the present disclosure may
be implemented using existing components of the wind turbine. As
such, a user is not required to purchase, install, and maintain new
equipment. Moreover, the system may be integrated with a broader
control system, such as, but not limiting of, a wind turbine
control system, a plant control system, a remote monitoring system,
or combinations thereof.
Referring now to the drawings, FIG. 1 illustrates a perspective
view of one embodiment of a wind turbine 10 that may implement the
control technology according to the present disclosure. As shown,
the wind turbine 10 generally includes a tower 12 extending from a
support surface 14, a nacelle 16 mounted on the tower 12, and a
rotor 18 coupled to the nacelle 16. The rotor 18 includes a
rotatable hub 20 and at least one rotor blade 22 coupled to and
extending outwardly from the hub 20. For example, in the
illustrated embodiment, the rotor 18 includes three rotor blades
22. However, in an alternative embodiment, the rotor 18 may include
more or less than three rotor blades 22. Each rotor blade 22 may be
spaced about the hub 20 to facilitate rotating the rotor 18 to
enable kinetic energy to be transferred from the wind into usable
mechanical energy, and subsequently, electrical energy. For
instance, the hub 20 may be rotatably coupled to an electric
generator 24 (FIG. 2) positioned within the nacelle 16 to permit
electrical energy to be produced.
The wind turbine 10 may also include a wind turbine controller 26
centralized within the nacelle 16. However, in other embodiments,
the controller 26 may be located within any other component of the
wind turbine 10 or at a location outside the wind turbine. Further,
the controller 26 may be communicatively coupled to any number of
the components of the wind turbine 10 in order to operate such
components and/or to implement the steps of the present disclosure
as described herein. As such, the controller 26 may include a
computer or other suitable processing unit. Thus, in several
embodiments, the controller 26 may include suitable
computer-readable instructions that, when implemented, configure
the controller 26 to perform various different functions, such as
receiving, transmitting and/or executing wind turbine control
signals. Accordingly, the controller 26 may generally be configured
to control the various operating modes (e.g., start-up or shut-down
sequences), de-rate or up-rate the wind turbine, control various
components of the wind turbine 10, and/or implement the various
steps of the method described herein as will be discussed in more
detail below.
Referring now to FIG. 2, an internal view of one embodiment of the
nacelle 16 of the wind turbine 10 shown in FIG. 1 is illustrated.
As shown, the generator 24 may be coupled to the rotor 18 for
producing electrical power from the rotational energy generated by
the rotor 18. For example, as shown in the illustrated embodiment,
the rotor 18 may include a rotor shaft 34 coupled to the hub 20 for
rotation therewith. The rotor shaft 34 may, in turn, be rotatably
coupled to a generator shaft 36 of the generator 24 through a
gearbox 38. As is generally understood, the rotor shaft 34 may
provide a low speed, high torque input to the gearbox 38 in
response to rotation of the rotor blades 22 and the hub 20. The
gearbox 38 may then be configured to convert the low speed, high
torque input to a high speed, low torque output to drive the
generator shaft 36 and, thus, the generator 24. The wind turbine 10
may also include a converter (not shown) configured to connect the
generator 24 to the grid and to ensure a constant energy supply.
More specifically, the converter is configured to convert a
predetermined torque demand into rotational power to drive the
generator 24.
Each rotor blade 22 may also include a pitch adjustment mechanism
32 configured to rotate each rotor blade 22 about its pitch axis
28. Further, each pitch adjustment mechanism 32 may include a pitch
drive motor 40 (e.g., any suitable electric, hydraulic, or
pneumatic motor), a pitch drive gearbox 42, and a pitch drive
pinion 44. In such embodiments, the pitch drive motor 40 may be
coupled to the pitch drive gearbox 42 so that the pitch drive motor
40 imparts mechanical force to the pitch drive gearbox 42.
Similarly, the pitch drive gearbox 42 may be coupled to the pitch
drive pinion 44 for rotation therewith. The pitch drive pinion 44
may, in turn, be in rotational engagement with a pitch bearing 46
coupled between the hub 20 and a corresponding rotor blade 22 such
that rotation of the pitch drive pinion 44 causes rotation of the
pitch bearing 46. Thus, in such embodiments, rotation of the pitch
drive motor 40 drives the pitch drive gearbox 42 and the pitch
drive pinion 44, thereby rotating the pitch bearing 46 and the
rotor blade 22 about the pitch axis 28. Similarly, the wind turbine
10 may include one or more yaw drive mechanisms 66 communicatively
coupled to the controller 26, with each yaw drive mechanism(s) 66
being configured to change the angle of the nacelle 16 relative to
the wind (e.g., by engaging a yaw bearing 68 of the wind turbine
10).
Still referring to FIG. 2, the wind turbine 10 may also include one
or more sensors 48, 50, 52 configured to measure or monitor various
wind parameters and/or one or more operating conditions of the wind
turbine 10. For example, in various embodiments, the sensors may
include blade sensors 48 for measuring a pitch angle of one of the
rotor blades 22; generator sensors 50 for monitoring the generator
24 (e.g. torque, rotational speed, acceleration and/or the power
output); and/or various wind sensors 52 for measuring various wind
parameters, such as wind speed, wind peaks, wind turbulence, wind
shear, changes in wind direction, air density, or similar. It
should also be understood that any number or type of sensors may be
employed and at any location. For example, the sensors may be Micro
Inertial Measurement Units (MIMUs), strain gauges, accelerometers,
pressure sensors, angle of attack sensors, vibration sensors, Light
Detecting and Ranging (LIDAR) sensors, camera systems, fiber optic
systems, anemometers, wind vanes, Sonic Detection and Ranging
(SODAR) sensors, infra lasers, radiometers, pitot tubes,
rawinsondes, other optical sensors, and/or any other suitable
sensors. It should also be appreciated that, as used herein, the
term "monitor" and variations thereof indicates that the various
sensors may be configured to provide a direct measurement of the
parameters being monitored or an indirect measurement of such
parameters. Thus, the sensors may, for example, be used to generate
signals relating to the parameter being monitored, which can then
be utilized by the controller 26 to determine the actual
parameter.
Referring now to FIGS. 3 and 4, there are illustrated block
diagrams of various embodiments of the controller 26 and the
processor 58 according to the present disclosure. As shown in FIG.
3, the controller 26 may include one or more processor(s) 58, a
wind parameter estimator 56, and associated memory device(s) 60
configured to perform a variety of computer-implemented functions
(e.g., performing the methods, steps, calculations and the like and
storing relevant data as disclosed herein). In further embodiments,
the one or more processor(s) 58 may operate independently from the
controller 56. Additionally, the controller 26 may include a
communications module 62 to facilitate communications between the
controller 26 and the various components of the wind turbine 10.
Further, the communications module 62 may include a sensor
interface 64 (e.g., one or more analog-to-digital converters) to
permit signals transmitted from the sensors 48, 50, 52 to be
converted into signals that can be understood and processed by the
processors 58. It should be appreciated that the sensors 48, 50, 52
may be communicatively coupled to the communications module 62
using any suitable means. For example, as shown in FIG. 3, the
sensors 48, 50, 52 are coupled to the sensor interface 64 via a
wired connection. However, in other embodiments, the sensors 48,
50, 52 may be coupled to the sensor interface 64 via a wireless
connection, such as by using any suitable wireless communications
protocol known in the art.
As used herein, the term "processor" refers not only to integrated
circuits referred to in the art as being included in a computer,
but also refers to a controller, a microcontroller, a
microcomputer, a programmable logic controller (PLC), an
application specific integrated circuit, and other programmable
circuits. Additionally, the memory device(s) 60 may generally
comprise memory element(s) including, but not limited to, computer
readable medium (e.g., random access memory (RAM)), computer
readable non-volatile medium (e.g., a flash memory), a floppy disk,
a compact disc-read only memory (CD-ROM), a magneto-optical disk
(MOD), a digital versatile disc (DVD) and/or other suitable memory
elements. Such memory device(s) 60 may generally be configured to
store suitable computer-readable instructions that, when
implemented by the processor(s) 58, configure the controller 26 to
perform various functions including, but not limited to,
determining one or more wind parameters of the wind turbine 10,
determining and selecting an appropriate operational set point for
various wind turbine components, transmitting suitable control
signals to implement control actions to prevent loads from damaging
the wind turbine, and/or various other suitable
computer-implemented functions. In addition, the wind parameter
estimator 56 may be considered software that utilizes a plurality
of operating conditions to calculate, in real-time, the current
wind parameter. Further, the wind parameter estimator 56 may
comprise firmware that includes the software, which may be executed
by the processor 58. Further, the wind parameter estimator 56 may
be in communication the various sensors and devices of the wind
turbine 10.
Referring still to FIG. 3, in one embodiment, the processor 58 may
receive one or more signals from the sensors 48, 50, 52 that are
representative of one or more wind parameters or one or more
operating conditions of the wind turbine 10. The wind parameters
may be reflective of a wind gust, a wind speed, a wind direction, a
wind acceleration, a wind turbulence, a wind shear, a wind veer, a
wake, or similar. Alternatively, the wind parameter estimator 56
may estimate the wind parameter(s) as a function of various
operating data. The operating data may include any one or
combination of the following: a pitch angle, a generator speed, a
power output, a torque demand and/or speed, a tip speed ratio, a
rotor speed, or similar. Accordingly, the wind parameter estimator
56 is configured to implement a control algorithm having a series
of equations to determine the estimated wind parameter. As such,
the equations are solved using the operating data and/or
conditions, one or more aerodynamic performance maps, one or more
look-up tables (LUTs), or any combination thereof.
Referring now to FIG. 4, a schematic diagram to further illustrate
the functionality of the processor 58 according to the present
disclosure is illustrated. As mentioned, the processor 58
determines at least one real or estimated wind parameter at the
wind turbine 10. In one embodiment, one or more filters or
S-functions (labeled 70) may be utilized to improve the stability
of the measured and/or estimated wind parameters due to high
variations in the measured and/or estimated values. In one
embodiment, for example, the filter 70 may be a low-pass filter. In
another embodiment, the filter 70 may be a band-pass filter. In
additional embodiments, the filter 70 may be any other suitable
filter known in the art. The low-pass filter filters the high
frequency signals from the plurality of wind parameters, thereby
providing more reliable data. In addition, the low-pass filter as
described herein may be a filter that passes low-frequency signals
but attenuates (i.e. reduces the amplitude of) signals with
frequencies lower than a cutoff frequency. In further embodiments,
the low-pass filter may be used in conjunction with a high-pass
filter. Further, any number of low-pass filters or high-pass
filters may be used in accordance with the present disclosure. As
such, the high-pass filter may pass high-frequency signals but
attenuate signals with frequencies lower than a cutoff frequency.
The high-frequency signals may be then subtracted from the raw
signal such that only the low-frequency signals remain.
In addition or alternatively, the processor 58 may input the
filtered or unfiltered wind parameters into an S-function 70 to
provide a more accurate parameter estimation. In one embodiment,
the S-function 70 is a mathematical equation having an S-shape. For
example, in one embodiment, the S-function 70 may be represented
by: y=k/(1+a*exp(b*x)), wherein k, a, and b are parameters of the
S-curve, x is the input, and y is the output. It should be
understood by those skilled in the art that the S-function 70 may
also be any other suitable mathematical function, e.g. a Sigmoid
function. In addition, the processor 58 may include any other
suitable algorithm or function.
The processor 58 is also configured to determine a variance 72 of
the monitored operating condition and/or the wind parameters,
wherein the variance is indicative of an oscillation occurring in
one or more wind turbine components. For example, in one
embodiment, the sensors 48, 50, 52 are configured to monitor the
operating condition, e.g. a fluctuating generator speed, and store
the monitored operating condition in one or more memory device(s)
60. If the variance 72 of the operation condition indicates that
the oscillation is within a certain frequency band, e.g. a range of
frequencies including one or more resonance frequencies of one of
the wind components, then the processor 58 is configured to de-tune
or modify the frequency of the oscillation such that it is outside
of the frequency band. In one embodiment, the frequency band can be
a predetermined frequency band. For example, the predetermined
frequency band may include a range of frequencies determined by
Design of Experiment (DOE). Further, the predetermined frequency
band may be a computed frequency band having manual or automated
perturbation test results. Alternatively, the frequency band can be
dynamically computed by performing automated perturbation tests and
analyzing the test results based on the data collected.
In addition, the variance 72 generally refers to the up-and-down
adjustments to the generator speed due to up-and-down wind speeds
experienced by the wind turbine 10. In another embodiment, the
variance 72 may be the up-and-down measurements or estimates of the
high wind speed. The varying "high" wind speeds typically refer to
wind speeds above 15 meters/second (m/s) and are indicative of a
high turbulence intensity. Typical "high" turbulence intensity
levels range from about 5% to about 20% for the wind turbine. It
should be understood; however, that "high" wind speeds and "high"
turbulence intensity as described herein are illustrative terms and
are not meant to limit the present disclosure in any manner.
Further, even though the average wind speed may remain within
design limits, such up-and-down adjustments to the generator speed
and/or up-and-down measured or estimated wind speed tend to excite
resonance frequencies in various wind turbine components. As such,
even relatively small periodic changes in the generator speed
and/or wind speed can produce large amplitude oscillations in the
various wind turbine components, thereby causing damage. For
example, in one embodiment, the resonance frequency causes
edge-wise loads in the rotor blade 22. As mentioned, edge-wise
loads are loads in the chord-wise direction between the leading
edge and the trailing edge and extend in the rotor plane. Flap-wise
loads are perpendicular to edge-wise loads and extend out of the
rotor plane. Edge-wise loads are typically higher than flap-wise
loads because there is more material in the edge-wise direction. It
should also be understood that a resonance frequency or vibrational
energy may be found in any other wind turbine component and is not
limited to the rotor blades 22.
In still further embodiments, the processor 58 may also calculate a
standard deviation of the monitored operation condition as part of
determining the variance 72. For example, in one embodiment, the
sensors 48, 50, 52 may monitor or measure the operating condition
and send corresponding signals to the processor 58, which is
capable of storing the monitored operating condition over a
predetermined time period in one or more memory device(s) 60. As
such, the processor 58 can be configured to calculate the standard
deviation of the monitored operating condition. The standard
deviation as described herein indicates the variation or dispersion
that exists from an average (mean) or expected value. In additional
embodiments, any other calculated value indicative of a variability
of the monitored operation conditions may be used.
In addition, the processor 58 may include one or more adaptive
filters to smooth and stabilize the standard deviation calculation
of the monitored operating condition to improve system stability.
For example, the one or more adaptive filters can be any type of
filter capable of accommodating to the changing conditions of the
system, such as time constants, gain, and/or similar. For example,
the one or more filters may be low-pass filters, high-pass filters,
band-pass filters, or any other suitable filters known in the art.
As such, the variance 72 may be determined from the operating
condition sensor data, from the calculated standard deviation of
the monitored operating condition, or a combination thereof.
Still referring to FIG. 4, the processor 58 is also configured to
determine a modified operating set point based the variance 72 of
the monitored operating condition and/or the real or estimated wind
parameters. In a further embodiment, the processor 58 is configured
to select between the modified operating set point and a current
operating set point when the variance 72 indicates that the
oscillation occurring in the wind turbine component is with a
certain frequency band that can potentially damage the component,
such as a range including the resonance frequency of the component.
The current or non-modified operating set point is meant to
encompass any suitable set point set by the controller 26 for
operating the wind turbine 10 in normal wind and operational
conditions (i.e. the variance 72 is not indicative of an
oscillation having a frequency within the frequency band). As such,
if the variance 72 indicates that the oscillation has a frequency
with the frequency band, the controller 26 can change the operating
set point to modify the frequency of the oscillation to a modified
frequency that is outside of the frequency band so as to reduce
oscillation loads on the wind turbine 10 induced by high turbulence
intensity. If such oscillation loads are not detected, the
controller 26 may continue operation in its current state. In
additional embodiments, the processor 58 may be configured to input
the operating set point into a filter, an S-function, or both,
which are configured to smooth and stabilize the transition to the
modified operating set point.
In various embodiments, the operating set point may also take into
consideration an electrical capability of the wind turbine 10. As
used herein, the term "electrical capability" of the wind turbine
10 is meant to encompass the amount of electricity that the wind
turbine 10 is capable of producing. As such, the present system and
method limits the operating set point such that it is electrically
achievable. The electrical capability of the wind turbine 10 may be
a function of, at least, the torque availability as determined by
the converter of the wind turbine 10. In other words, the available
torque that drives the generator 24 and produces electricity is
limited by the currents and voltages supplied by the converter. As
such, the torque availability cannot be increased arbitrarily
because it is limited by the converter. Accordingly, the present
disclosure is capable of determining the torque availability or
torque limit and prohibiting the wind turbine 10 from operating
above such limit.
In view of the variance 72 and/or the operating set point, the
controller 26 may operate the wind turbine 10 by implementing any
suitable control action. It should be understood that the control
action as described herein may encompass any suitable command or
constraint by the controller 26. For example, in several
embodiments, the control action may include temporarily de-rating
or up-rating the wind turbine 10 to modify the frequency of
oscillations of one or more wind turbine components, thereby
preventing oscillation loads from damaging the components. Further,
de-rating and up-rating of the wind turbine 10 is a function of
wind speed. As such, the adjustments made to de-rate or up-rate the
wind turbine 10 during high wind speeds have a greater effect at
decreasing loads than at lower wind speeds.
Up-rating the wind turbine, such as by up-rating torque, generator
speed, or both, may temporarily increase power output of the wind
turbine 10 wherein wind speeds indicate benign or non-turbulent
conditions. Similarly, de-rating the wind turbine may include
de-rating generator speed, torque, or a combination of both. In
further embodiments, the wind turbine 10 may be de-rated by
pitching one or more of the rotor blades 22 about its pitch axis
28. More specifically, the controller 26 may generally control each
pitch adjustment mechanism 32 in order to alter the pitch angle of
each rotor blade 22 between 0 degrees (i.e., a power position of
the rotor blade 22) and 90 degrees (i.e., a feathered position of
the rotor blade 22). As such, in one embodiment, the controller 26
may command a new pitch set point (e.g. from 0 degrees to 5
degrees), whereas in another embodiment, the controller 26 may
specify a new pitch constraint (e.g. a constraint to ensure that
subsequent pitch commands are at least 5 degrees).
In still another embodiment, the wind turbine 10 may be temporarily
de-rated or up-rated by modifying the torque demand on the
generator 24. In general, the torque demand may be modified using
any suitable method, process, structure and/or means known in the
art. For instance, in one embodiment, the torque demand on the
generator 24 may be controlled using the controller 26 by
transmitting a suitable control signal/command to the converter in
order to modulate the magnetic flux produced within the generator
24.
The wind turbine 10 may also be temporarily de-rated by yawing the
nacelle 22 to change the angle of the nacelle 16 relative to the
direction of the wind. In further embodiments, the controller 26
may be configured to actuate one or more mechanical brake(s) in
order to reduce the rotational speed of the rotor blades 22,
thereby reducing component loading. In still further embodiments,
the controller 26 may modify a load bank and/or a buck boost
mechanism. In yet another embodiment, the controller 26 may actuate
one or more airflow modifying elements, such as one or more blade
flaps, vortex generators, add-ons, and/or similar. the controller
26 may be configured to perform any appropriate control action
known in the art. Further, the controller 26 may implement a
combination of two or more control actions.
Referring now to FIG. 5, a flow diagram of method 100 for reducing
oscillation loads in a wind turbine due to high turbulence or
combined with other environmental conditions according to one
embodiment of the present disclosure is illustrated. As shown, the
method 100 includes a first step 102 of determining at least one
wind parameter at the wind turbine, e.g. a wind speed. A next step
104 includes monitoring an operating condition of the wind turbine,
e.g. a fluctuating generator speed. In addition, the method 100 may
also include a step 106 of determining, by a processor, a variance
of at least one of the monitored operating condition or a plurality
of the wind parameters, wherein the variance is indicative of an
oscillation occurring in one or more wind turbine components. In a
next step, the method 100 includes determining, by a processor, an
operating set point based on the variance (step 108). The method
100 may also include operating the wind turbine based on the
operating set point when the variance indicates that the
oscillation has a frequency within a certain frequency band so as
to modify the frequency, wherein the modified frequency is outside
of the frequency band and reduces oscillation loads occurring at
the one or more wind turbine components induced by high turbulence
intensity. (step 110).
This written description uses examples to disclose the invention,
including the best mode, and also to enable any person skilled in
the art to practice the invention, including making and using any
devices or systems and performing any incorporated methods. The
patentable scope of the invention is defined by the claims, and may
include other examples that occur to those skilled in the art. Such
other examples are intended to be within the scope of the claims if
they include structural elements that do not differ from the
literal language of the claims, or if they include equivalent
structural elements with insubstantial differences from the literal
languages of the claims.
* * * * *